As Southeast Europe approaches 2026, hydropower emerges as a critical element shaping the region’s energy landscape, particularly with Serbia at its core. The interplay between hydropower generation, market prices, and overall system stability is increasingly recognized as pivotal for economic outcomes. This duality manifests starkly in how hydro resources respond to varying hydrological conditions: abundant rainfall leads to price suppression and lower imports, while drought conditions can exacerbate scarcity and volatility, especially in a market sensitive to thermal generation costs.
Serbia’s electricity supply relies heavily on its hydropower fleet, which consists of 16 plants totaling approximately 3,015 MW of installed capacity. In 2024, hydropower accounted for around 32.2% of the electricity generated by Electric Power Industry of Serbia (EPS), with historical averages indicating an annual output of about 10.6 TWh. However, projections for 2025 suggested a significant drop in hydro generation due to drought conditions, potentially falling to around 8 TWh. This decline sets the stage for critical evaluations in 2026 regarding the implications of varying hydrological scenarios.
Forecasting the hydropower landscape for 2026 requires a focus on two main drivers: winter reservoir levels and prevailing regional pricing influenced by carbon emissions and gas markets. As of mid-January 2026, European carbon prices were trading between €90–92 per tonne, suggesting a higher marginal cost for thermal generation across interconnected markets. Such pricing dynamics are crucial because they create a floor for day-ahead prices during peak demand periods; when thermal units dominate the marginal supply and CO₂ prices are elevated, hydropower’s role expands beyond mere volume production to include its capacity to provide balancing services during times of volatility.
The initial conditions at the start of 2026 indicate a favorable winter reservoir situation across Europe, with levels reported as higher than in previous years. While this does not guarantee a wet summer ahead, it diminishes the likelihood of entering the year under acute scarcity conditions. For Serbia specifically, strong reservoir levels exiting winter would enable strategic water management throughout spring and summer, allowing for reduced import reliance and enhanced flexibility during peak demand hours.
The base-case scenario for Serbia in 2026 anticipates hydroelectric output returning to approximately 9.5–11.0 TWh—reflecting normalization following the drought year—while still aligning closely with EPS’s long-term average generation figures. This anticipated output is vital not only for energy supply but also for influencing price structures; an increase in hydro production typically results in fewer “import hours,” compressing peak price spreads and improving ancillary service availability due to hydro’s rapid ramping capabilities compared to thermal units.
In an optimistic scenario characterized by abundant rainfall throughout the spring season, hydro generation could exceed historical averages, reaching between 11.5–13.0 TWh. This outcome would facilitate reduced thermal dispatch and lower import needs while enhancing Serbia’s ability to export energy during peak periods—thus generating additional revenue even amidst lower domestic prices due to increased export volumes and balancing services.
Conversely, should dry conditions persist into summer—a downside case could see hydro production drop back down to the range of 7.5–9.0 TWh—mirroring or slightly improving upon the previous year’s drought profile. This scenario poses significant macroeconomic risks as it translates into heightened thermal generation needs and increased imports that drive up day-ahead prices while also inflating balancing costs due to diminished hydro contributions during times when solar and wind resources are variable.
The relationship between hydro shortfalls and import requirements is crucial; a deficit of just 2–3 TWh can dramatically elevate import levels during key months when electricity demand peaks. In such instances where import-hour prices range from €110–150/MWh due to CO₂ constraints, these shortfalls could translate into substantial financial burdens—potentially costing Serbia between €220–450 million depending on severity—thereby impacting fiscal stability if retail tariffs require smoothing interventions.
Market trends will further amplify these dynamics; elevated CO₂ pricing will structurally raise thermal costs across the region while creating more pronounced convexity in day-ahead pricing curves during tight supply hours. Hydro’s economic value becomes particularly pronounced under these conditions as it can command higher prices when deployed strategically for peak load management rather than being sold at baseload rates.
The evolving landscape of balancing markets will also play a significant role as cross-border integration continues amid increasing shares of variable renewables like wind and solar power. Hydro’s inherent capability for providing fast ramping services without fuel cost volatility positions it favorably against thermal plants that may struggle under similar pressures during dry years.
Comparatively within Southeast Europe, Serbia’s position is reinforced by its interconnections with neighboring nations such as Albania—which experiences greater volatility due to its reliance on hydropower—and Romania’s more diversified energy mix that often stabilizes regional flows amidst fluctuating supply-demand scenarios.
Looking ahead into trading behaviors for 2026: if hydro output aligns with base-case expectations (9.5–11.0 TWh), Serbia may maintain a neutral-to-modest exporting status through transitional seasons while becoming a modest importer during high-demand winter evenings with manageable balancing costs throughout the year. In contrast, should an upside scenario materialize (11.5–13.0 TWh), exports could increase significantly during spring months leading to improved price stability across the region.
For stakeholders monitoring developments into early 2026, key indicators will include reservoir levels post-winter and movements in CO₂ pricing trends which directly impact market perceptions regarding risk premiums associated with potential imports or scarcity spreads throughout summer months.
The overarching narrative surrounding Serbia’s hydropower sector emphasizes its dual role as both an energy resource provider and macroeconomic stabilizer; effective management of this resource will be paramount in mitigating risks associated with drought years while leveraging favorable conditions when they arise.
